ML20154S049
| ML20154S049 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 05/13/1985 |
| From: | Bosnak R Office of Nuclear Reactor Regulation |
| To: | Crutchfield D Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML20151K803 | List: |
| References | |
| FOIA-85-511 NUDOCS 8603310286 | |
| Download: ML20154S049 (58) | |
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UNITED STATES b-
'f T. -..' i NUCLEAR REGULATORY COMMISSION
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MAY I 31555 l E.*-:0F.Al:.""JI. FO' : Cer.ris f:. Crutchfield, Assistar.t Directcr Eivisicr of Licensing
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Robert Bcsnak, Acting Assister.t Director f0r Co renents and Structures Encineerire Divisien of Engineering
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As recuested in yocr memo dated April 19, 1955, en above subject, we have reviewed the River Eenc Technical Specifica-icn 3.3.7.2 on Seisric Instru: ertation and 3.7.10 en Structural Settleme :t.
We find tnese Technical Sceci'ica-icns, as written, are accepttble and no charges are i
l recuired. A co::y of these Technical Soecifications is attached.
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RobertBosnak,ActinodssistantDirector for Components ard Structures Engineering 2
Division of Engineeri,ng Encicsure: As stated cc:
J. Kr.ignt G. Lear i
L. Feller P. Kuc
' I H. Feik J. Cher i
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INSTRUMENTATION
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SEISMIC MONITORING INSTRUMENTATION nF?
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LIMITING CONDITION FOR OPERATION 3.3.7.2 Th'e seismic monitoring instrumentation shown in Taole 3 be OPERABLE.
..- shall APPLICABILITY: At all times.
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ACTION:
With one or more of the above requirec seismic monit a.
inoperable for more than 30 days, prepare and submitoring instrumen to the Commission pursuant to Specification 6 9 2 withia Special Rep 10 days outlining the cause of the malfunction and the plans f n the next restoring the instrument (s) to OPERAELE status.
or b.
The p avisions of Specifications 3.0.3 and 3.0 4 are not ap l p cable.
SURVEILLANCE REOUIREMENTS i
b 4.3.7.2.1 demonstrated OPERABLE by the performance of the t
TIONAL TEST and CHANNEL CALIBRATION operations at the Yrecu e
- r. CHANNEL FUNC-Table 4.3.7.2-1.,
nc es shown in
- 4. 3'.' 7. 2. 2' during a seismic event greater than or equal te 0 01g sn
,R OPERAltLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and a CHANNEL CALIBRATION pe c
e restored to following the seismic event.
i, and analyzed to determine the magnitude of the vibratory groun Report shall be prepared and submitted to the Convaission p i
n.
A Soecial tion 6.9.2 within 10 days describin'g the magnitude
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ursuant to Specifica-resultant effect upon unit features important to safetyfrequency spectrum and i
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L RIVER BEND - UNIT 1 3/4 3-70 l
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" '" 4 SEISMIC MONITORING INSTRUMENTATION W/stpjj' f MINIMUM INSTRUMENTS AND SENSOR LOCATIONS MEASUREMENT INSTRUMENTS RANGE l' OPERABLE 1.
Triaxial Time-History Accelerographs Reactor 81dg Mat EL 70'0" a.
Reactor Bldg Ext Shield Wall 0 2 1. 0 g 1
b.
EL 232'0" Reactor Bldg Orywell EL 151'0" 0 2 1. 0 g 1
c.
d.
Free Field - Grace Level 0: 1.0 g 1
0 ! 1. 0 g 1
2.
Triaxial Peak Acceleregraphs Reactor 81dg SLCS Stora a.
Reactor Bldg - RHR Inj.ge Tank 0 2 10.0 g 1
- i b.
Piping 0
10.0 g 1
Aux. Bldg Service Water Piping c.
0 2 10.0 g 1
3.
Triaxial Seismic Switenes Reactor Bldg Mat El 70'0" a.
0.025 to 0.2,5 g 1(*)
4.
Triaxial Response-Spectrum Recorders 4
Reactor Bldg Mat EL 70'0" a.
b.
Reactor Bldg Floor EL 141'0" 022g 1(a)-
Auxiliary Bldg Mat EL 70'0" 022g 1
c.
Auxiliary Bldg Floor EL 141'0" 022g d.
1 0
2g-1 (a)With reactor control room indication and ann unciation.
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TABLE 4. 3. 7. 2-1 By n 'l -
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- 4; SEISMIC MONITORING INSTRUMENT 8' ION SURV CHANNEL INSTRUMENTS AND SENSOR LOCATIONS CHANNEL FUNCTIONAL
' CHANNEL -
CHECK TEST CALIBRATION 1.
Triaxthi Time-History Accelerographs Reactor Bldg. Mat EL 70'0" a.
M b.
Reactor Bleg. Exit Shield Wall SA- - -
R El 232'0" M
SA R
i Reactor Bleg. Drywell EL 151'0" c.
M d.
Free Field-Grade Level M
R SA SA R
2.
Triaxial Peak Accelerographs Reactor Sidg. SLCS Stora a.
Reactor Bldg. - RHR Inj. ge Tank NA b.
NA Piping NA R
Aux. Bldg. Service Water Piping c.
NA NA R
NA R
3.
Triaxial Seismic Switches Reactor 81dg. Mat EL 70'0" M(a) a.
34 g
4 Triaxial Response-Spectrum Recorders l
Reactor B1dg. Mat EL 70'0' a.
M b.
Reactor Bldg. Floor EL 141'0" SA R
NA Auxiliary Bldg. Mat EL 70'0" SA' R
c.
NA d.
Auxiliary Bldg. Floor EL 141.0" NA R
1 NA NA R
(*)E,xcept seismic trigger.
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,3 PLANT SYSTEMS 3/4.7.10 STRUCTURAL SETTLEMENT
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LIMITING CONDITION FOR OPERATION
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3.7.10
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predicted values as showr. in Table 3 7101 Structu ructures shall be within the a.
Reactor Suilding b.
Auxiliary Building Fuel Building c.
d.
Control Building e.
Diesel Generator Building f.
Stancby Cooling Tower, Basin and Pump Hous APPLICABILITY:
e At all times.
AEION:
With the measured structual settlement outside 'of 7 the Commission pursuant to'Specificatithe predicted settleme to demonstrate the co'ntinued struttur l ia submit a Special Report to on 6.9.2 within the next 30 days provi and plans to monitor the settlement of the aff ntegrity of the affected structur a
ected structure (s) in the future.
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3 SURVEILLANCE REQUIREMENTS 3
4.7.10 demonstrated to be within the predict dThe structural se settlement values:equired structures shall be e
4 a.
At least once per 92 days, using at least th until there is essentially no movement durinree markers per 4
b.
g those 92 days.
At least once per 24 months, using at le for at least 10 years.
!i ast one marker per st*veture, Basis Earthquake (OBE), using at least thFoll c.
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1 reater than an Operational ree markers per structure.
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WASHINGTON, D. C. 20555
.\\.....f May 13,1985 2
MEMORANDUM FOR: Dennis M. Crutchfield, Assistant Director for Safety Assessment, DL FROM:
R. Wayne Houston, Assistant Director h
for Reactor Safety, DSI
SUBJECT:
REVIEW OF THE TECHNICAL SPECIFICATIONS FOR THE P
RIVER BEND GENERATING STATION i
The Containment Systems Branch (CSB) ha:; completed its review of those portions of the River Bend Generating Station Technical Specifications that fall within its review responsibility. Enclosed is a marked-up copy of the 4
i affected Technical Specifications (T.S.).
' si 1
The bulk of the suggested cnanges are either editorial in nature or clarifications. A few, however, are more substantive and are sumarized below.
,j Item 3.6.1.9 and 3.6.2.7:
, ;;ij These T.S. are interim criteria for the first cycle. The applicant has comitted to an informaticn gathering program during the first cycle to e
devel.ap a basis for future usage of the containment and drywell purge system lu and to propose consistent T.S. for any changes. As written, the interim
- 34 criteria will end 3 months after completion of the first refueling outage.
A l r.j 1000' hour limitation will become effective after this time if no T.S. changes
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are proposed.
!: :lj Item 3.6.2.7:
1 Since the applicant has not provided assurance that the drywell purge velves will close under accident conditions, the valves should be locked closed until' M;
the valves are properly qualified. This qualification pro 5 ram is currently
- F) unscheduled by the applicant.
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.-1 id CONTACT:
F. Eltawila, CSB: DSI
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- ,u Dennis M. Crutchfield.
It should be noted that this T.S. restriction may cause undue hardship during the initial heat-up test period due to the potential release of amonia from drywell insulation. The staff will work closely with the applicant to seek resolution of this difficulty.
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m R. Wayne Houston, Assistant Director for Reactor Safety, DSI cc w/o entiosure:
R. Bernero H. Thompson T. Novak W. Butler i
S. Stern E. Butcher i
cc w/ enclosure:
D. Houston Lj
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DEFINITIONS PRESSURE BOUNDARY 1.EAKAGE 1.30 PRESSURE BOUNOARY LEAKAGE shall be leakage through a non-isolable fault.
in a reactor coolant system component body, pipe wall or vessel wall.
PRIMARY CONTAINMENT INTEGRITY - FUEL HANDLING 1.31 PRIMARY CONTAINMENT INTEGRITY - FUEL HANDLING shall exist when; All containment penetrations required to be closed during accident a.
conditions are closed by at least one manual valve, blind flange, or deactivated automatic valve secured in its closed position.
b.
All centainment hatches are closed, Each containment air lock is in compliance with the requirements of c.
Specification 3.6.1.4.
(O PERA* TION 4 t_
CONDI TIONS ;
PRIMARY CONTAINMENT INTEGRITY - OPERATING
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1.32 PRIMARY CONTAINMINT INTEGRITY - OPERATING shall, exist when; All containment penetrations required to be closed during dccident a.
conditions are either:
1.
Capable of being closed by an OPERABLE containment automatic isolation system, or 2.
Closed by at least one manual valve, blind flange, or ceacti-vated automatic. valve secured in its closed position, except as provided in Specification 3.6.4.
.b.
All containment equipment hatches are closed and sealed.
Each containment air lock is in compliance with the requirements of c.
Specification 3.6.1.4.
The containment leakage rates are witnin the limits of Specification d.
3.6.1.2.
The suppressior, pool is in compliance with the requirements of Spec 4-e.
fication 3.6.3.1.
f.
The sealing mechanism associated with each primary containment penetra-tion; e.g., welds, bellows or 0 rings, is OPERABLE.
PROCESS CONTROL PROGRAM (PCP) 1 1.33 The PROCESS CONTROL PROGRAM shall contain the current formula, sampling, analyses, tests, and determinations to be made to ensure that the processing and packaging of solid radioactive wastes based on demonstrated processing or actual or simulated wet solid wastes will be accomplished in such a way as to l
assure comsliance with 10 CFR Part 20, 10 CFR Part 61, 10 CFR Part 71 and RIVER BEND - UNIT 1 1-6 MR26 E w
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DEFINITIONS Federal and State requiations and other requirements governing the disposal of the radioactive waste.
RATED THERMAL POWER 1.34 RATED THERMAL POWER shall be a total reactor core heat transfer the reactor coolant of 2894 MWT.
REACTOR PROTECTION SYSTEM RESPONSE TIME 1.35 REACTOR FROTECTION SYSTEM RESPONSE TIME shall be the time when the monitored parameter exceeds its trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids.
The response time may be measured by any series of sequential, overlaoping or total steps such that the entire response time is measured.
REPORTABLE EVENT 1.36 A REPORTABLE EVENT shall be any of those conditions specified in 10 CFR 50.73.
ROD DENSITY 1.37 ROO DENSITY shall be the number of control' rod notches inserted as a fraction of the total number of control rod notches.
is equivalent to 100% ROD DENSITY.
All rods fully inserted
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SECONCARY CONTAINMENT INTEGRITY - FUEL BUILDING 1.38 SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDING shall exist whe All Fuel Building penetrations required to be closed during acci-a.
dent conditions are closed by valves, blind flanges, or dampers secured in position.
b.
All Fuel Building equipment hatch covers are installed, The Fuel Building Charcoal Filtration System is in compliance with c.
the requirements of Specification 3/4.6.5.6.
d.
At least one door in each access to the Fuel Building is closed, except for routine entry ano exit of personnel and equipment.
The pressure within the Fuel Building is maintained in compliance e.
with the requirements of Specification 4.6.5.1.2.a.
L O PEC ATTONA L d(CND1'YSOY$ 3 g
SECONDARY CONTAINMENT INTEGRITY - OPERATING
( McyCp[ lf 2Omd3) 1.39 SECONDARY CONTAINMENT INTEGRITY - OPERATING shall exist when:
All Auxiliary Building penetrations, Fuel Building penetrations anc a.
Shield Building annulus penetrations required to be closed ouring accident conditions are either:
RIVER BEND - UNIT 1 1-7 APR 2 6 E65
i CONTAINMENT SYSTEMS PRIMARY CONTtINMENT INTEGRITY - FUEL HANDLING LIMITING CONDITION FOR 0_PERATION
- 3. 6.1. 2 PRIMARY CONTAINMENT INTEGRITY - FUEL HANDLING shall be ma APPLICABILITY:
O&ERATIONAL,CQ_NDITIONf
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ACTION:
Without PRIMARY CONTAINMENT INTEGRITY - FUEL HANDLING, suspend handling fuel in the primary containment, CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
SURVEILLANCE REQUIREMENTS
- 4. 6.1. 2 PRIMARY CONTAINMENT INTEGRITY - FUEL HANDLING shall be e.. s r. __ _yc _
e %.o ww,nt ha c.-
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Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> pr~ior t6and at least once per e"*. *- OPERATIONAC a.
gha>t COND1_TIO4" by verifying that all primary containment penetrations sb>-*
qwo J
ir. TeMc
.0." 1 required to be closed during accident concitions are closed by hatches, valves, blind flanges, or deactivated automatic
, valves secured in position.
b.
By verifying each containment air lock is in compliance with the requirements of Specification 3.6.1.4.
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t "When handling irradiated fuel in the primary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
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gQ1h RIVER BEND - UNIT 1 3/4 6-2 4
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CONTAINMENT SYSTEMS PRIMARY CONTAINMENT LEAKAGE LIMITING CONDITION FOR OPERATION 3.6.1.3 Primary containment leakage rates shall be limited to:
An overall integrated leakage rate of less than or~ equal to La, a.
0.26 percent by wcight of the pricary containment a'iFper 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at Pa, 7.6 psig.
b.
A combined leakage rate of less than 0.60 La for all penetrations and all valves subject to Type B and C tests when pressurized in accordance with Table 3.6.4-1 of Specification 3.5.4 A leakage rate of less than 340 scfh for each of the valve groups c.
identified below when tested in accordance with the surveillance requirements of 4. 6.1.3. f.
1.
Division I MS-PLCS Valves and Division I PVLCS Valves 2.
Division II MS-PLCS Valves and Division II PVLCS Valves' DivisionIM{PLCSValvesandallfirstoutboardPVLCSValves 3.
f,-s d.
A combined leakage rate of less than or equal to 13,500 cc/hr for all penetrations shown in Table 3.6.1.3-1 as annulus bypass leakage paths when pressurized to Pa, 7.6 psig.
O e.
A combined leakage rate of less than or equal to 170,000 cc/hr, for
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all valves shown in Table 3.6.4-1 to be g uipped with PVLCS, when_...__ __
pressuri:ed to Pa, 7.6 psig.
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A combined leakage rate nf less than or equal to 1 gpm times the total number of containment isolation valves in hydrostatically tested lines P
per Table 3.6.4-1 which penetrate the primary containment, when tested a
- psig, g.WG i
APPLICABILITY:
tion 3.6.1.1.
When PRIMARY CONTAINMENT INTEGRITY.is required per Specifica-t 8
ACTION:
With:
l a.
The measured overall integrated primary cor tainment leakage rate equaling cr exceeding 0.75 La or,',
b.
The measured combined leakage rate for all senetrations and all valves subject to Type B and C tests exceeding 0.6) La, or The measured leakage rate' greater than or ecual to 340 scfh for each c.
valve grouping identified in 3.6.1.3.c.1, 3.6.1.3.c.2 or 3.6.1.3.c.3, i
or RIVER BEND - UNIT 1 3/4 6-3
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CCNTAINMENT SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)
I ACTION (Continued) d.
The combined leakage rate for all penetrations shown in Table 3.6.1.3-1 as annulus bypass leakage paths exceeding 13,500 cc/hr, The combined leakage rate, for all valves shown.in Jable.3.6.4-1 to e.
be. equipped with PYLCS eedjrig 170,00 I
T'heMrYdhondde'd"g#7r[tNoka,0 cc/hr, or leakag ll containment isolation valv in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment exceeding 1 gpm times the total number of such
- valves, restore:
The overall integrated leakage rate (s) to less than 0.75 La as a.
applicable, and b.
The combined leakage rate for all penetrations and all valves subject to Type 8 and C tests to less than or eaual to 0.60 La, and l'
The measured leakage rate to less than 340 scfh for each of the valve c.
groupings identified in 3.6.1.3.c.1, 3.6.1.3.c.2, and 3.6.1.3.c.3 and d.
The combined leakage rate for all penetrations shown in Table 3.6.1.3-1 as annulus bypass leakage paths to less than or equal to 13,500 cc/hr and l.
The combined leakage rate, for all valves sh'own in Table 3.6.4-1 to be e.
ipped with PVLCS. M 170,000 cc/hr, and e combined lea +kage rat /:Me-than or equal to WW r
.p.:en 1.c ae ps U a.3r t
for all per Table 3.6.4-1 containment isola-f f.*
tion valves in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment to less than or equal to 1 gpm times the total number of such valves, prior to increasing reactor coolant system temperature above 200*F.
l SURVEILLANCE REQUIREMENTS 4.6.1.3 The primary containment leakage rates shall be demonstrated at the follow-l l
ing test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4 (1972):
Three Type A Overall Integrated Containment Leakage Rate tests shall a.
oe conducted at 40 2 10 month intervals during shutdown at Pa, 7.6 psig, during each 10 year service period.
The third test of each set shall be conducted during the shutdown for the 10 year plant inservice inspection.
W RIVER BEND - UNIT 1 3/4 6-4
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If any periodic Type A test fails to meet 0.75 La, the' test schedule for subsequent Type A tests shall be reviewed and approved by the Commission.
If two consecutive Type A tests fail to meet 0.75 La, a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet 0.75 La, at.which time the above test schedule may be resumed.
The accuracy of each Type A test shall be verified by a supplemental c.
test which:
1.
Confirms the accuracy of the test by verifying th'at the differ-ence between the supplemental test data and the Type A test data is within 0.25 L, - (Lc
- U am * 'o) 5 0.25 L,) where L = supplemental test results; L = superimposed leakage; e
e L, = measured Type A leakage.
2.
Has duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.
3.
Requires the quantity of gas injected into the primary containment or bled from the primary containment during the supplemental test to be between 0.75 La and 1.25 La.
d.
Type B and C tests shall be conducted with gas at Pa, 7.6 psig", at
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intervals no greater than 24 months except for tests involving:
l 1.
Air locks, i
2.
Main steam positive leakage control system (MS-PLCS) valv'es and PVLCS valves, 3.
Penetrations using continuous leakage monitoring systems, b
t 4.
Primary containment isolation valves in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment, and ij 5.
Purge supply and exhaust isolation valves with resilient material seals.
Air locks shall be tested and demonstrated OPERABLE per Surveillance e.
Requirement 4.6.1.4.
I otal sealing air leakage into the primary containment at a ?.est pressure of 11.5 psid for main steam isolation valves and E psid for penetration leakage control system sealed valves shall be tested at least once per 18 months.
g "Unless a hydrostatic test is required per-Table 3.6.4-1.
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CONTAINMENT SYSTEMS M
bI rde. $De;,x.i SURVEILLANCE REQUIREMENTS (Continued) g.
Typ: 0 ;;ri:di: t;;t: :r; r:t re;;ir:
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-menit:r;d :;j th: "-ie:ry Cert:2 ::nt P:n:t :ti "
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,c:;id: th: y:t:: i: OPE2LE p;r Sp::i'i::ti:r 2.5.1. L g/
Type B test; for electrical penetrations employing a'cTnt'inuous leakage monitoring system shall be conducted at Pa, 7.6 psig, at intervals no greater than once per 3 years.
coell be les+ed cass.
h f.
Leakage from isolation valves that are sealed with the PVLCSTmay bej
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pd F 2 W puts,1fka D
[ excluded when determinino the combined leak.aoe rateC:,. An'.ne 4441.
(f ry'+r :nd valves +ee-pressurized to at least s,-14 Pah.-% psig,-aae 9,(.g 3
th:~:::1 :3;t;; ::;;;it3 i; :d:;;;t: t: raintzi :ytter pr:::ur; f:S
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if.
Primary containment isolation valves in hydrostatically te:ted lines per Table 3.6.4-1 which penetrate the primary containment shall be leak tested at least once per 18 months.
) X.
Purge supply and exhaust isolation valves with resilient material seals shall be tested and demonstrated OPERABLE per Surveillance i
r Requirement 4.6.1.9.3.
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The provisions of Specification 4.0.2 are not applicable to Specifications 4.6.1.3.a, 4.6.1.3.b, 4.6.l.3.d, 4.6.1.3.e and
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TABLE 3.6.1.3-_1 ANNULUS BYPASS LEAKAGE PATHS 1.
LEAKAGE PATHS TO THE FUEL BUILDING PEF.ETRATION Containment air lock IJRE*0RA2 O
2.
LEAKAGE PATHS TO THE AUXILIARY. BUILDING VALVE NO.
VALVE NO.
PENETRATION (DIV. 1)
(DIV. 2) 1KJB*I31 IHVR*A0V165 1HVR*A0V123
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IKJB*605E ICMS*SOV31A ICMS*SOV35C 1KJB"60SF ICMS*SOVf'31C ICMS*SOV35A IKJB*601B ISSR*$0V131 ISSR*SOV130 Containment air lock IJRB"DRA 1 CRD removal hatch O*
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6 CONTAINMENT SYSTEMS PRIMARY CONTAINMENT AIR LOCKS
[ N'N,N N W u., '.d LIMITING CONDITION FOR OPERATION 3.6.1.4 Each primary containment air lock shall be OPERABLE with:
Both doors closed excEpt when the air lock is being used for normal a.
transit entry and exit through the containment, theh aTTeast one air lock door shall be closed, and b.
An overall air lock leakage rate in compliance with the limits of Specification 3.6.1.3.d when pressurized to Pi, 7.6 psig, and The inflatable seal system air flask pressure 1 4 M psig.
10 c.
APPLICABILITY:
'JPERATIONAL CONDITIONS 1, 2*, 3, and #.
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ACTION:
With one primary containment air lock door inoperable:
a.
1.
Maintain at least the OPERABLE air lock door closed and either re i
the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or lock the OPERABLE air lock door closed.
2.
Operation may then continue until performance of the next required overall air lock leakage test provided that the OPERABLE air lock door ij is verified to be locked closed at least once per 31 days, i
i Otherwisehn CPErancna conoinens o.1.. v3 3.
in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.be in at least H A.
Drur-se on omwH~tCu.4 s # *tm era 1 f /.
The provisions of Specification 3.0.4 are not applicable.
l I
b.
With a primary containment air lock inoperable, except as a result of an l
l inoperable air lock door, maintain at least one air lock door closed
. la OMAr restore the inoperable air lock to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or
!a
- 1, in at least HOT SHUTDOWN witnin the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDO
'n o' nu" -
7
!?
within the fol_ lowing 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
". l a opmNmd censh
.Unssar M i
dith one primary containment air lock door inflatable seal system air flask l
c.
pressure instrumentation channel inoperable, restore the inoperable channel to OPERABLE status within 7 days or verify air flask pressures to be 1 psig at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
I 1
"See Special Test Exception 3.10.1.
pe,u,y
- When irradiated fuel is being handled in the.:::nd: g-containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
l T
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pkuhn RIVER BEND - UNIT 1 3/4 6-8 APR 2 6 E y
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INSERT A _ ( 4, pag 3/4 b 6) suspend ~all operations involving handling of irradiated fuel in the containment, C0KE ALTERATIONS, and operations with a' potential for draining the reactor vessel.
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.n CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS
- 4. 6.1. 4 Each primary containment air lock shall be demonstrated OPERABLE:
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following each closing, except when the air lock is a.
being used for multiple entries, then at least once per 72' hours, by verifying seal leakage rate is in compliance with the7iniits in Specification 3.6.1.3.d when the gap between the door seals is pressurized to Pa, 7.6 psig.
j By conducting an overall air lock leakage test at Pa, 7.6 psig, and i
b.
verifying that the overall air lock leakage rate is within.its limit:
1.
At least once per 6 months,"
t
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2.
?tior to establishing PRIMARY CONTAINMENT INTEGRITY - OPERATING when maintenance has been performed on air lock that could dM% % iede h.:iaffect the air lock sealing capa'ilit
-C 4 1.sc6%. e_.a il At least cnce per 6 months by verifying that only one door in eac c.
air lock can be opened at a time.
d.
By verifying ttle door inflatable seal system OPERABLE by:
ij 1.
.t At least once per 7 days, verifying seal air flask pressure to be greater than or equal to 46 psig.
90 2.
At least once per 18 months, conducting a seal pneumatic system leak test and verifying that system pressure does not decay more t
than 1-46 psig from 1GG-osig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
-1 1.12 40 4
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CONTAINMENT SYSTEMS PRIMARY CONTAINMENT INTERNAL PRESSURE b
D j
LIMITING CONDITION FOR OPERATION
- 3. 6.1. 7
-0.3 and +0.3 psig. Primary containment internal pressure shall be maintained b AFPt.ICABILITY:
OPERATIONAL CONDITIONS 1, 2, and 3.
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ACTION:
/With the primary containment t:
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outside of the specified limits, restore the
_ pressure
^' pressure to within and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.the limit SURVEILLANCE REOUIREMENTS C
4.6.1.7 within the limits at least once per 12 ecurs.The primary containment inte D
gpt7,i N RIVER BEND - UNIT 1 3/4 6-12 l
p CONTA!*ENT SYSTEMS PRIMARY CONTAIWENT AVERAGE AIR TEMPERATURE W
j s1d LIMITING CONDITION FOR OPERATION
- 3. 6.1. 8 Primary containment avarage air temperature shall not exceed les*F'.
90 APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
With the primary containment average air temperatur 90 HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
the SURVEILLANCE REQUIREMENTS
- 4. 6.1. 8 The primary containment average air temperature shall be the arithmetic average of the temperatures at the following locations and shall be determined to be within the limit at least once per 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:
Elevation Azimuth" a.
- 167'
- 72*
b.
s167'
$108*
c.
- 167' s 37'
~~
d.
- 122' l
s170*
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+ 15' f.
- 119'
- 270*
g.
- 139' s 66*
h.
- 119' s117' i.
- 119'
$219' j.
- 119'
$322' "At least one reading from each elevation is. required for an average calculation.
However, if all instrumentation is OPERABLE, all readings should be usec.in the calculation.
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RIVER BEND - UNIT 1 3/4 6-13 O
e E
CONTAINMENT SYSTEMS PRIMARY CONTAINMENT PURGE SYSTEM 8
LIMITING CONDITION FOR OPERATION
- 3. 6.1. 9 The primary containment purge 36 inch supply and exhaust isolation valves shall be OPERABLE and closed except:
Each 36 inch purge valve may be open for purge system operation with a.
such operation limited to 2000Nours par 365 days for' reduci:g airborne activity and pressure control, and b.
If the SGTS is in the purge flow path then both trains of the SGTS must be OPERABLE, but only one train of SGTS may be operating in tree purge flow path.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
With a 36 inch primary containment pyJr e supply and/or exhaust isola-i a.
tion valve (s) open for more than 2000Thours per 365 days, close and/or seal the 36 inch valve (s) or othenvise isolate the penetration within 4 hcurs or be in.at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
b.
With both SGTS trains in operation in the purge flow path and/or without i
both SGTS OPERABLE with one SGTS in the purge flow path, discontinue 36 inch purge system operation and close the open 36 inch valve (s) or otherwise iso' late the penetration (s) within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or be in at least HOT SHUTDOWN within the riext 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
t With a crimary containment purge supply and/or exhaust isolation valve (s) with resilient material seals having a measured leakage rate exceeding the limit of Surveillance Requiremr,t 4.6.1.9.3, restore the inocerable valve (s) to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the l
following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
l i >
li SURVEILLANCE REQUIREMENTS
\\'
-l-4.6.1.9.1 Each 36 inch primary ainment purge supply and exhaust isolation valve shall be verified to be ealed losed at least once per 31 days.
4.6.1.9.2 The cumulative time that the 36 inch primary containment purge sucply and/or exhaust isolation valves have been open during the past 365 days sna11
,be determined at least once per 7 days.
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PENETRATION VALVE LEAKAGE CONTROL SYSTEM 0 3 *,
E" b PJJ I LIMITING CONDITION FOR OPERATION 3.6.1.10 Two independent penetration valve leakage control system (PVLCS)
~
divisions shall be OPERABLE.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
With one PVLCS division inoperable, restore the inoperable division to OPERABLE status within 7 days or be in a+ least HOT SHUT 00WN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hcurs.
i SURVEILLANCE REQUIREMENTS 4.6.1.10 Each PVLCS division shall be demonstrated OPERABLE:
At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by verifying division PVLCS accumulator a.
pressure greater than or equal to 101 psig.
b.
During each COLD SHUTDOWN, i.f not performed within the previous 92 days, by cycling each remote, manual and automatic motor operated valve through at least one complete cycle of full travel.
At least once per 18 months by/ >
c.
JFI(IPerformance of a functional test which includes simulated actuation of the system throughout its operating sequence, and verifying that each automatic valve actuates to its correct position and that a sealing pressure greater than or equal to JHf psig is established in each sealing valve, and 22.
2.
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CONTAINHENT SYSTEMS L
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SURVEILLANCE REQUIREMENTS (Continued)
By verifying the personnel door inflatable seal system OPERABLE e.
1.
At least once per 7 days verifying seal air flask pressure to be greater than or equa' to ne-psig, aio 2.
At least once per 18 months conducting a seal pnet.,matic system leak test and verifying that system pressure does not cecay more than -Fr psig from 166 psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
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CONTAINMENT SYSTEMS ORWELL AIR LOCKS 7.
gl)'4fdJ.
in.n[ I LIMITING CONDITION FOR OPERATION
~
3.6.2.3 The drywell a_ir lock shall be OPERABLE with:
i Both doors closed except when the air lock is being used. fr-normal transit a.
entry and exit through the drywell, then at least one air lock door shall be closed, and b.
An overall air lock leakage rate of less than or equal to 11.85 scf per hour at 3.0 psid, and The inflatable seal system air flask pressure > ;PDd'psig.
c.
APPLICABILITY: OPERATIONAL C0hDITIONS 12", and 3.
ACTION:
=
With one drywell air lock decr inope:able:
a.
l
~
i 1.
Maintain at least the OPERABLE air lock door closed and either i
restore the inopert.ble air lock door to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or lock the OPERABLE air lock door closed.
1 i !
2.
Operation may then continue provided that the OPERABLE air lock door i :
is verified to be locked closed at least once per 31 days.
3.
Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
, c 4.
The provisions of Specification 3.0.4 are not applicable.
b.
With the drywell air lock inoperable, except as a result of an inoperable air lock door, maintsir at least one air lock door closed; restore the inoperable air lock to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN with following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
With one inoperable drywell air lock door inflatable seal system air flask t
pressure instrumentation channel, restore the inoperable channel to OPERABLE status within 7 days or verify air flask pressure to be >,9 least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
_ 1G6'psig at a
"See special Test Exception 3.10.1.
i APR 0 6 %.-
RIVER BEND
'JNIT 1 3/4 6-20 l
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A CONTAINMENT SYSTEMS a
SURVEILLANCE REQUIREMENTS 4.6.2.3 The drywell air lock shall be demonstrated OPERABLF:.
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following each closing, excspt when the air lock is a.
being used for multiple entries, then at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, by verifying seal leakage rate less than or equal to 4 05;cf per hour when the gap between the door seals is pressurized to 3.0 psic.
NM b.
Bypressurizingtheairlockto19.2 psi [andconductinganoverallair lock leakage test at 3.0 psid and verifying that the overall air iock i
leakage rate is within its limit:
1.
At least once per 6 month 2.
Prior to establishing ORYWELL INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing capability.
t By verifying that only one door in the air lock can be opened at a time, c.
prior to drywell entry if not performed within the past six months.
d.
By verifying the door inflatable seal system OPERABLE by:
k' 1.
At least once per 7 days verifying seal air flask pressure to be greater than or equal to,lM psig.
. )'
2.
40 At least once per 18 months conducting a seal pneumatic system leak test and verifying, that system pressure does not decay mere than kW psig from WJ psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
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CONTAINMENT SYSTEMS ORYVELL VENT AND PURGE LIMITING CONDITION FOR OPERATION t&m xd 5 6 w '
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3.6.2. / The drywell vent and purge system supply and exhaust valves shall be 1
closed /except, while in OPERATIONAL CONDITION 3, the drywell vent and purge system 24 inch valves may be open during operation of th rywell vent and purge made of the containment cooling system for up to 9 ours per 365 days for the purpose of reducing drywell airborne radioactivity levels prior to and during personnel entries or for controlling drywell pressure. The drywell may be vented for up to ourt per 365 days in OPERATIONAL CONDITIONS 1 and 2, for controlling drywell pressure by opening the 24 inch drywell purge supply or exhaust valves; however, only one line may be o n at a time.
s APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
CL-With the drywell vent and purge system supply or exhaust valves open a.
in.0PERATIONAL CONDITIONS 1 gmr 2 and the 36 inch primary containment purge system supply or exhaust valves open, immediately close the drywell vent and purge system valves or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
SZ.
[. -
.With the drywell vent and purge system supply or exhaust valves open b.
(
during OPERATIONAL CONDITIONS 1 a g 2 for more than 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> per 365 days, immediately close the drywell vent valves or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
With both the drywell purge supply and>xhaust valves open at the c.
i same time in OPERATIONAL CONDITIONS 1 W 2, immediately isolate either the supply or exhaust line; otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
With the drywell vent or purge mode of the containment cooling system d.
in operation, during OPERATIONAL CONDITION 3, for more than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br /> per 365 cays, immediately close the drywell vent and purge 24 inch valves or be in at least COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
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CONTAINPtENT SYSTEMS SURv'EILLANCE REQUIREMENTS 4.6.2.7 At least once per 7 days, determine the cumulative time that:
M 1.
The drywell vent and purg? system supply es-exhaust valves have been open during OPERATIONAL CONDITIONS 1 and 2 during the-r,ast 365 days, and Pur$L 2.
The drywell vent and purge mode of the containment c ?'.; system has been in operation during OPERATIONAL CONDITION 3 within the past 365 days.
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CONTAINMENT SYSTEMS a
LIMITING CONDITION FOR OPERATION (Continued)
ACTION:
(Continued) 2.
With the suppression pool average water temperature greaterthan a) 95'F for sort than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and THERMAL POWE L greater than 1% of RATED THERMAL POWER, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within'tne next 3
b) 110*F place the reactor mode switch in the Shutdown position and operate at least one residual heat removal loop in the suppression pool cooling mode.
3.
With the suppression pool average water temperature greater than 120'F, depressurize the reactor pressure vessel to less than-200 psig within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, With only one suppression chamber water level indicator CPERABLE k i
c.
and/or with fewet indicators, one in each ofthan eight suppression pool water temperature i
the inoperable indicator (s@) to OPERABLE status whithin 7
(
i i
verify suppression chamber water level and/or temperature to be
'i within the limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
d.
With no suppression chamber water level indicators OPERABLE and/or i
'with fewer than seven suppression pool water temperature indicators covering at least seven locations, OPERABLE, restore at least one water level indicator and at least six water temperature indicators to OPERAB'.E status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.6.3.1 1
The suppression pool shall be demonstrated OPERABLE:
By verifying the suppression pool water volume tc be within the a.
limits at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
i I
b.
At least once per'24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, in OPERATIONAL CONDITION 1 or 2,' by
. verifying the suppression pool average water temperature to be less than or equal to 95 F, except:
1.
At least once per 5 minutes, during testing which adds heat to the suppression pool, by verifying the suppression pool average water temperature less than or equal to 105'F.
RIVER BEND - UNIT 1 APR 2 6 N.as 3/4 6-28 9
.~. ---
CONTAINMENT SYSTEMS 3/4.6.4 PRIMARY CONTAINMENT AND ORYWELL ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.4 The primary containaent and drywell isolation valves in Tabie 3.6.4-1 shall be OPERABLE with isolation times less than or equal to those shown in Table 3.6.4-1.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3 ACTION:
~
With one or more of the primary containment or drywell isolation valves shown in Table 3.6.4-1 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> either:
1.
Restore the inoperable valve (s) to OPERABLE status, or 2.
Isolate each affected penetration by use of at least one deactivated automatic valve secared in the isolated position,* or 3.
Isolate each affected penetration by use of at least one closed manual or blind flange.*
>' W Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in
/
COLD SHUTLOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, f
SURVEILLANCE REQUIREMENTS 4.6.T.1 Each isolation valve'shown in Table 3.6.4-1 shall be demonstrated j
i OPERABLE prior to returning the valve to service, after maintenance, repair or.
replacament work is_ performed on the valve or its associated actuator, control
-(
I or power circuit, by cycling the valve through at least one compitte cycle of full travel and verifying the specified isolation time.
t 4.6.4.2 Each automatic isolation valve shown in Table 3.6.4-1 shall be demon-j strated OPERABLE during COLD SHUTDOWN or REFUELING at least once per 18 months 4
by verifying that, on an isolation test signal, each automatic isolation valve actuates to its isolation position.
4.6.4.3 The isolation time of each power operated or automatic valve shown in Table 3.6.4-1 shall te determined to be within its limit when tested pursuant to Specification 4.0.5.
i 7
1 solation valves closed to satisfy these requirements may be reopened on an intermittent basis under zdministrative controls.
L y
P M M g & c A m 3. c.it d'A m d y L:c A FM ew.
A pct s masar,, a w.tw w M cc w dA AC T.! M 2.
i o~ d 3
.e, n d pwvedd L.L h - n m e & A.
yn; t s T.
RIVER BEND - UN 1
3/4 6-32
., y y.R caldt,
e4cStwd mqcd4 u d S aff W '" Y u
ACTIM A. tile.ne L Q QsnpQ_cw ftfc2m el 1
. _. - _.. _ _.... ~...
\\
TABLE 3.6.4-1 (Continued) i 2g CONTAINMENT AND DRYWELL ISOLATION VALVES
=
E o
MAXIMUM SECON04kV VALVE PENETRATION 1501All0N TIME CONTAINNENT c
' NUMBER NUMBER VALVE GROUP (Seconds)
BYPASS PATH (4}
{
(Yes/No) a.
Automatic isolation Valves Primary Containment *I (Continued)
I 1.
1G33*MOVF028 IKJB*24
+ 17 20.9 Yes(U 1G33*MOVF040 IKJ8*26
+ 15 24.2 No IG33*MOVF001(b)(f)-
IKJ8*27 t 16 19.8 No R
IG33*MOVF053 IKJB*Z129
+ 19
- 5. 5 No IG33*MOVF034N T
IG33*MOVF039N IKJ8*Z4
+ 1 5' 20.9 Yes W IKJB"Z6
+ if 24.2 No IG33*H0VF004ND IKJB"Z7 7
6.6 No i
IG33*MOVF054N IKJB"Z129
+ if 5.5 No IWCS*MOV178 IKJ8"Z5
'l 12.1 Yes IO IWCS*MOV172 IKJ8*25 1
12.6 Yes(U IE22*MOVF023IJI IKJB*Zil 1
50 No IE12*MOVF024AIJI IKJ88Z24A 10 63.8 No IE12*H0VF0llAIJI IKJB"Z24A 10 34.I No IE21*M0VF0128JI IKJS*Z24A 10 57.2 No IE12*E0VF024BIJI IKJB"Z24B 10 63.8 No IE12*MOVF0llBIJI IKJBaZ248 10 30.8 No y
lE 12*."nvF021(J )
IKJB*Z24C 10 97.9 No em-ra 15FC*MOV119 IMdB2261k3 B *226 1
68 No Z
15FC*M0V120 1 Kd B 2 P7 i k 3 B
- 2 '1 7 1
62 7 No a
15FC8H0V122 IKJB*Z27 1
63 8 No 15FC*MOVl39 iMdB22& 1 XJ B
- 22 8 1
3916 Na ISIC"H0VI21 IMdB22& 1 XJB*2 28 1
39.6 No n
-~~
f 3:=i:a
~rg H
u
.\\
TABLE 3.6.4-1 (Continued)
CONTAlletENT ANO DRYWELL ISOLATION VALVES MAXIMUM SECONDARY VALVE PENETRATION i
NUMBER ISOLATION TIME CONTAlletENT cE NUMBER VALVE GROUP (Seconds)
BYPASS PATH (-f-)-
i w
(Yes/No)
W a.
Automatic Isolation Valves I
1.
Primary Containment ') (Continued) 3DFR*A0V102(DI b) 1DFR 19RF*A0V101I IKJB*Z35,1DR B a 2 36 1
N/A No IKJ8*235,1 DRB
- 136 1
N/A No IDER*A0V127 IKJ8*238,1 DR 8
- 2 31 1
N/A No IDER*A0V126 IKJB"Z38,1 DR 8
- H1 1
N/A No IFPW"MOV121 IKJB*Z41 1
34.1 YesIII 15AS*MOV102 IKJB"Z44 1
22.0 YesIll 11AS*MOV106 IKJ8*Z46 1
18.7 Yes(#I O
1CCP*MOV138 IKJB"Z48 1
22.0 No ICCP*HOV158 IKJB"Z49 1
23.1 No ICCP*MOV159 IK.18*249 1
24.2 No 15WP*MOV5A IKJB*l53A 1
50.6 No 15WP"H0V58 IKJB'Z538 1
53.9 No 1HVN*MOV102 IKJB*Z131 1
31.9 YesllI IllVN*MOV128 IKJB"Z131 1
28.6 YesIII i
lilVN*MOV127 IKJB"Z132 1
2 /. 5 Yes III ICN5*MOV125 IKJB*Z134 1
22.0 Yes III i
lrm Y
e m
5 3:n i
=
es i
y i
i
4
=
_ TABLE 3.6.4-1 (Continued) s CONTAINMENT AND ORYWELL ISOLATION VALVES m
CIB9 MAXINUM SECONDARY VALVE PENETRATION e
ISOLATION TIME CONTAI N NT fi NUMBER NtMIER VALVE GROUP (Seconds)
BYPASS PATHf+F (Yes/No) s.
Automatic Isolation Valves Primary ContainmenL(a) (Continued) 1.
IE51*MOVF063((b) b)
IKJ8*Z15 2
- 9. 9 No IE51*MOVF076 IKJ8*Z15 2
13.4 No IE51*MOVF064 IKJ8*Z15 2
9.9 No l
IE51*MOVF031W IKJ8*Zl6 2
30.5 No IE51*MOVF077 IKJ8*Z17 3
14.2 No T
IE51*MOVF078 IKJ8*2188,C 3
16.5 No M
IHVR*A0V165 IKJ8*Z31 8
3 No IHVR*A0V122 IKJ8*Z31 8
3 No 1HVR*A0V128 IKJ8*233 8
3 No IHVR*A0V166 IKJ8*Z33 8
3 No 155R*50V130 IKJ8*Z6018 le 1 3
No 155R*50V131 IKJ8*Z6018 la 1 3
No at I
hk'^*
i C'N 4
- 23 g
y ru H
a y.
a
TABLE 3.6.4-1 (Continued)
,i CONTAINMENT AND DRYWELL ISOLATION VALVES
- =
b MAXIMUM SECONDARY VALVE PENETRATION i
ISOLATION TIME CONTAIMENT c5 NUMBER NUMBER VALVE GROUP (Seconds)
BYPASS PA1H(4) l (Yes/No) a.
Automatic Isolation Valves i
2.
DrywellIII (Continued)
ICPM*NOV2A 10RB*l57A le 1 33 No ICPM*MOV4A 10RB"Z57A le t 13 No ICPM*MOV2B 1DRB*ZS78 16 1 33 No ICPM*MOV4B 10RB"Z57B le 1 33 No ICPM"MOV3A 10RB*l5BA le 1 33 No i
ICPM*MOVIA IDRB*Z58A le 1 33 No m
ICPM*MOV3B 10RB*Z5BB 14 1 33 No t
J.
ICPM*H0VIB 10RB"Z5BB 1& L 33 No 1833*A0VF019 10RB"Z449 9
5 No 1833*A0Vf020 IDRB"Z449 9
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_ TABLE 3.6.4-1 (Continued) 1ts 3
8 8 E
CONTAINHENT AND ORYWELL ISOLATION VALVES m*o SECONDARY
]
VALVE PENEIRAi!ON CONTAIM4ENT NUMBER
_ NUMBER c
BYPASS PATH (+)
=
(Yes/Mo)
-4 e
b.
Manual Isolation Valves Primary Containment 'I (Continued)
I 1.
ICll*MOVF08 I')
lt-?P*MOVIB4l*).
IKJ8"Z29 No i
I IKJ8*Z33 It'PP*MOV105 ') ~
No f
IKJ8"Z33 15WP*MOV56/A *)
No I
I IKJ8*Z52A 15WP*MOV507p'I No R
IKJ8*Z528 15WP*MOV81A
- No T
15WP*MOV818g IKJB"Z53A No IKJ8*Z538 15WP*M0Y503Af,'
No f:
IKJ8*Z53A No 15WP*MOV50gg)
IKJ8*Z538
,15WaMOVIB No II IKJ8*Z102 ISVV*MOVIA 'I No ICPP850V140 ")
IKJB*l103 No
~
ICMS*SOV350 ")
1KJB*231 I
No ICN5*50V318 ')
,IKJ8*I601E I
No ICMS*50V358 ')
,IKJ8*I601E I
No.
ICMS*50V310 'I IKJ8*Z601F No I
ICMS*SOV35C ')
IKJ8*I601F I
No ICMS*SOV31A ')
IKJB*2605E I
No I
IKJ8*2605E ICMS*SOV35A '))
No M
I IKJ8*2605F ICMS*SOV31C '
No IKJB*I605F No E
l M
r'=
I a,
DO
- i. <
o
~
==={
- Ji
TABLE 3.6.4-1 (Continued)
CONTAI N NT AND ORYWELL ISOLATION VALVES
--xo SECONDAR; VALVE PENETRATION HUMBER CONTAI N NT HUMBER c-BYPASS PATH (f)
(Yes/No)
-e b.
Manual Isolation Valves 2.
DrywellII 15AS*V489 10R8*Z45 I!AS*V79 No 10RB*I47 IHVM*V542 No 10R8*Z54 15WP*V205 No 10R8"Z54 J 5WP*V206 10R88Z55 No 15VV*V53 No 10R8*Ill2 w
)
IRCS*V132 No 10RBaZ152 1RCS*V131 No IDR88Z153 1
IRCS*V162 No 1098*I154 N
IRCS*V156 No 10R8*Z155 1RCS*V187 flo 10RB*Z156 IRCS*V186 No 10R8*Z157 IRCS*V217 No IDR8"Il58 IRCS*V211 No IDRB*Z159 ICMS*50V34A 11 o I
10RB*Z500 ICH5*50V348 'I No l
10R8*I430 ICMS*SOV34C 'I No q
10R8*Z499 ICMS*SOV34D 'I No sewas l
40MS*50V34A-1CfAS A SOV32AIeI IDR88Z428 No g 10R8*Z333 ICMS*SOV32GW No i
IDR8*Z335
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TA8LE 3.6.4-1 (Continued) g CONTAINHENT AND DRYWELL 150Lt.T10N VALVES
=m5 SECONDARY VALVE PENETRATION CONTAINMENT NUMBER
_ NUMBER g
SYPA55 PATH (4}
U (Yes/No) c.
Other Isolation Valves I
Primary Containment *I (Continued) 1.
lE12*RVF025 IO IE12*RVF030pM IKJ6*Z238 No IKJB'Z238 IE12*RVF101 @M IKJB*l238 No IE12*RVF0118 No IKJ8*Z238 15FC*V101 No 1KJ8*Z26 1
15FC*VJ50 No IKJ8"Z27 15FCaV351 No IKJ8*Z28 os j
ICll*VF122 No IKJS*Z29 10ER*V4 No IKJS*Z38 IDFR*V180 No IKJ88Z35 IFPW'V263 No IKJ8*Z41 15AS*V486 Yes III IKJB*I44 IIAS*V80 Yes III IKJ88Z46 YesVI ICCP*Vll8 IKJ8"Z48 ICCP*V160 No IKJS*Z49 15WP*V174 No IKJB*I57A 15WP8V175 No IKJB*I528 15VV*V9 No IKJB*Il02 15VV*V31 No 1KJ8*Z103 IHVN*V1316 No III g IKJ8*Z131 IHVN*V54I Yes IKJ8*Il32 Ye s -No III ICN5*V86 IKJS*Z134 YeslII F os g
3D i
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- %-j
~4
- 1
,i t
1A8tE 3.6.4-1 (Continued)
CONTAINPdNTANDORYWELiISOLATIONVALVES o
SECC4IDARY VALVE PD:DRAllDN NtHIER CONTAINMENT g
NUMBER BYPASS PAIN (f)
G 3 es/Mo) c.
Other Isolation Valves 2.
DrywellIII 1821*RVF047A 10R8*ZI36 No 1821*RVF041A 10R8*Z137 1821*RVF051G No 10R8*Z138 No IB21*RVF041L 10RB"Z139 No R
1921*RVF047C 10R8*ll40 No 1821*RVF041G 10RBall41 No T
1821*RVF051C 10RB*Il42 No e
1821*RVf041C 10RB*Z143 No IB21*RVF0478 10R88Z144 1821*RVF0418 No.
10R8*2145 1821*RVF0518 No IDRB*Z146 No IB21*RVF041F 10RB"zl47 1821*RVF047f No 10RB"Z148 IB21*RVF0410 No 10R882149 No IB21*RVt0470 10RB*Z150 1
IB21*RVF0510 No 10RBaZ151 No lE12*A0VF041A 10RB*Z22A J
No IE12*A0VF0418 10RB*l228 q
No maman E
I D
I o
g p
vi
-4
w.-.
TABLE 3.6.4-1 (Continued) m CDNTAINMENT AND DRYWELL ISOLATION VALVES m$
SECONDARY VALVE PENETRAllDN NtlMBER CONTAllMENT j
g HUMHER BYPASS PATHtt)
Z (Yes/No) c.
Other Isolation Valves i
2.
DrywellI I (Continued) 10FR*V4 IDR8*Z37A IDFR*V3 No IDR6*Z37A No IDFa*VI IDR8"Z378 No IDfR*V2 JDR8*Z378 No R
19ER*V14 3DRB*Z40A No IDER*V15 IDRB*I40A No i
IDER"V16 IDRB"Z408 No IDER*V17 1028*Z408 No 15AS*V487 IDRB"Z45 No IIAS*V78 IDRB*Z47 No ICCP*V119 IDRB"Z50 Ne 15WP*RV119 IDR8*ZS4 IC41*VU6tF004A No IDRB*ZS6 ko IC41*VU0(F0048 IDRBaZ56 ho IC41*Vf006 IDRB*Z56 No IC41*Vf007 IDRB*ZS6 No ICCP*V133 IDRS*l51 No M
+
"mem 5
2:a i
r --
m "U
1 mi
% -J
!l H
7
TABLE 3.6.4-1 (Continued)
B i
- g CONTAINMENT AND ORYWELL ISOLATION VALVES m$
SECONDARY VALVE PENEIRATION CONTAIMENT NUMBER NUMBER BYPASS PATHff4 c5 (Yes/No)
--e e--
c.
Other Isolation Valves Drywell(k) (Continued) 2.
IB21"Vf036A 10RB"Z107 No IB21*Vf036f 10RB"Z107 No 1821*Vf036G 10RB"Z107 No IB21*Vf036P 10RB*l107 No IB21*VfC39C 10RB'Z107 No 1821*Vf039H 10RB*2107 No i
IB21*VF039K ICRB*l107 No i
?;
1821*Vf0395 10RBal107 No IB21*Vf036J 10RB"Zll2 No IB21*Vf036L 10RB*lll2 Na IB21*Vf036M 10RB"Zll2 No 1821*Vf036N 10RB*Zll2 No IB21*VF036R 10RB*lll2 No IB21*Vf0398 10RB*Ill2 No s
1821*Vf0390 10RB*Zll2 No IB21*Vf039E 10RB"Zil2 No 1833*VF013A 10RB"Z133 No IB33*Vf017A 10RB*Z133 No IB33*VF0138.
10RB*Z135 No IB33*Vf017B 10RB*Z135 q
No ICMS*V41 10RB*I427 l
amme ICMS*V40 No g
10R8'IS01 No P
c.n v
tll3
- 23 i
t:m
'e
~i=g i.a
~'
wt
4
.i E
TABLE 3.6.4-1 (Continued) i E
CONTA! MENT AND DRWELL ISOLATION VALVES O
NOTES
{
(a)
Subject to test pressure of 7.6 psig.
(b) w Also isolates the drywell.
ICI' Testable check valve.
(d)
Opens on isolation signal.
(e)
Receives a remote manual isolation signal.
R III This line is scaled by the penetration valve leakage control system,IPVt.2.5)
T I9 This valve sealed by the main steam positive leakage control system (MS-PLCS) 5 W
gh} -AIs+o sys *.es +M. T e C teaksy tes ts.
V tadA w;I ska.2 ated
-tsdietet igh.,e..r p.,cretha heet ;;;;hr,I ba;r ::t!:t i:.;.:rature-(bpe}r d.c 1 A +o s t m
(3) v. lee is kvde s ts tesa lly lesk tested.
Valves-G33*=-lT001-1 TOO? ere the-enty-velves-4rn. ;;rr;:
-l i qu i d-cent ro l-sys t em-i n i tiation-s i gna lv 7 that-iselate-en-the t e *y (k)
Test pressure not applicable to these valves, m
I 2:
. g r--
=
.(_..
- s -
!q..
..s
- cy
,o To
?
m D.u
~1
!: s s'
Filit DRAFT CONTAINMENT SYSTEMS
, SURVEILLANCE REQUIREMENTS (Continued)
At least once per 18 months:
c.
1.
Verifying that one stancby gas treatment subsystem will draw down the Shield Building Annulus anc the Auxiliary Builcing to greater than or equal to and 0.25 inches of-ncuum water tively, and, gauge in less than or equal to M W and R seconds respec t73
- /
f,4. pgm e,q. f 12.nc A t:
30 L
egm 2.
Operating one standby gas treatmen subsystem [for one hour and maintaining the Shield Building annulus and the /wxiliary Build-ing greater than or equal to
.., and 0.25 inches of vacuum water gau flow rate not exceeding 2000 and 3000 cfm, respectively.
-0
~,n u,exa@
3.
Verifying that one fuel Building ventilation subsystem will draw down the Fuel Building to greater than 0.25 inches of vacuum ' ater gauge in less than or equal to 26 seconds, and p
.,,, %,g f ie,ect 4
Operating one Fuel' Building ventilation subsyste for one ou and maintaining greater than or equal to 0.25 inches of vacuum
)
water gauge in the Fuel Building awflow r
- 5000 cfm.
ot exceeding Q
m /44 k, 3
(
i J
L-l l
RIVER BEND - UNIT 1 A,C9 2 6 % 5 3/4 6-50
.a:..
a 9.*
~ V.,n
.... 2.::2 --
CONTAINMENT SYSTEMS N,h 7 f ddb 3/4.6.5 SECONDARY CONTAINMENT SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDING LIMITING CONDITION FOR OPERATION 3.6.5.2 SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDIN APPLICABILITY:
OFC'" TI:N" COM I'I:N' Ogg 6f Qg'fs,
ACTION:
Without SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDING susp irradiated fuel in the Fuel Building.
The provisions of Specification 3.0.3 are not applicable.
SURVEILLANCE REQUIREMENTS e
4.6.5.2 SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDING j
within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to and at least once per 7 days during handling of irradiated fuel in the Fuel Building cy verifying that:
N The pressure within the Fuel Building is less than or equal to a.
0.25 inches of vacuum water gauge.
J b.
All Fuel Building equipment hatch covars are installed.
At least one door in each access to the Fuel Building is closed except
~~
c.
for routine entry and exit.
d.
All Fuel Building penetrations, except the Fuel Building Ventilation System charcoal filtration systera penetrations, required to be closed during Fuel Handling accident concitions are closed by valves, blind flanges, or dampers secured in position.
When irraciated fuel is being handled in the Fuel Building.
RIVER BEND - UNIT 1 3/4 6-51
,-3%,.
ui d
- D" m
.weee====*
FINAL DRAFT CONTAINMENT SYSTCMS SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS LIMITING CONDITION FOR OPERATION 3.6.5.3 The secondary containment ventilation system automatic isolation dampers shown in Table 3.6.5.3-1 shall be OPERABLE with isolation times less than or equal to the times shown in Table 3.6.5.3-1.
APPLICABILITY: As shown in Table 3.6.5.3-1.
ACTION:
With one or more of the secondary containment ventilation system automatic isolation dampers shown in Table 3.6.5.3-1 inoperable, maintain at least one isolation damper OPERABLE in each affected penetration that is open, and within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> either:
a.
Restore the inoperable damper (s) to OPERABLE status, or b.
Isolate each affected penetration by usa of at least one deactivated automatic damper secured in the isolation position, or Isolate each affected penetration by use of at least one closed manual c.
valve or blind flange.
f-Y i
\\_.
Otherwise, in OPERATIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
t Otherwise, in Operational Condition
- suspend handling of irradiated fuel in the ::: -t y re*=4 = a+
C'""' ",LT:'LIC"E :n! wm di:n: Wa
.. cat:nti:1 Tm m o ;-";
^
. tion 3.0.3 are not applicable.
.;;; [;iThe provisions of Specifica-L# S"%
SURVEILLANCE REOUIREMENTS 4.6.5.3 Each secondary containment ventilation system automatic isolation damper shown in Table 3.6.5.3-1 shall be demonstrated OPERABLE:
Prior to returning the damper to service after maintenance. repair or a.
replacement work is performed on the damper or its associated actuator, control or power circuit, by cycling the damper through at least one complete cycle of full travel and verifying the specified isolation time.
F".w.A YY "Wnen irraciatsi Tuel is being handled in the
---'= y crt:in= :
P "'r.ng OCR: nLT:IdTIC": ad ;;;r**inne wi" :
i p; ten Q Tw. y 'ee re a.w.
u m.~q ye..~ 2. c. 4 c. a w v a ra:. v.. a.a + - i Ac. gic:6ce p.6sc,~ u udaa ~ 0 cen. g ~ e ~.a x 11. : ' t c fu,.
RIVER BEND - UNIT 1 3/4 6-52 APR 2 61985 c d a p.ci p e d p aL & w. a &' S.5 '.fyAM g
k <"
l ad<w ~ %c un,,,.,s. s n o,r a w : ca. m.= 1.P"
.q w.m m
s CONTAINMENT SYSTEMS STANDBY GAS TREATMENT SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.4 Two independent standby gas treatment subsystems shall be OPERABLE.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
With one standby gas treatment subsystem inaperable, restore the inoperable subsystem to OPERABLE status within 7 daysf or '- C':::
/
N'/. ::::::'::? ',
2 ;- O s be in at least HOT SHUTOCWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24. hours.
t SURVEILLANCE REQUIREMENTS i
i 4.6.5.4 Each stancty gas treatment subsystem shall be demonstrated OPERABLE:'
At least once per 31 days by initiating, from the control room, flow a.
through the HEPA filters and charcoal adsorbers and verifying that
+
the subsystem operates for at least 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> with the heaters-OPERABLE.
4 h
I i
l RIVER BEND - UNIT 1 3/4 6-56 aPR 2 6 EEE l
.. -. e;.A QNTAINNENTSYSTEMS FUEL BUILDING VENTILATION LIMITING _ CONDITION FOR OPERATION
- 3. 6. 5. 6 Two independent Fuel Building Yentilation Charcoal Filtration s u-systtms shall_be_0PERABLE, and in QPERATIONAL, CONDITION,*, one operating in the emergency mode.
i %,. J,, 4 APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3 and *.
ACTION:
With one Fuel Building Ventilation Charcoal Filtration subsystem a.
inoperable, restore the inoperable subsystem to OPERABLE status within 7 days, or:
1.
In OPERATIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTD0vH within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within that follhing 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
. i,
?
2.
In Operational Condition i
suspend handling of irradiated fuel i
i in the n;;rd: ;
-+a*"- :nt, COPE "LTE'"ICMS :-d :;;r;ti: a 5' vel 8,i,tdyq " ions of Specification 3 0 3 a':- d uf ' ; 2;.; :t:
.;;;C.. The provi-
.--^: ti:'
-j s
re not applicable.
t j
b.
With both Fuel Building Ventilation Charcoal Filtratica subsystems inoperable or with one not operating in the eme*gency mode in Opera-tional Condition
- Fust Smidig #wy ena*" ::.n,, ::" pend handling of irradiaced fuel in the ee+-
sus
- /LIC."jTIC C ;r :;;r: tic : rit'
,, J c... a 1 f:r dr;i 'n; th: r;;;;;,r nee.l..
The provisions of Specifica-
.j tion 3.0.3. are not applicable.
,j
!h SURVEILLANCE REQUIREMENTS Is j
4.6.5.6 Each fuel Building ventilation Charcoal Filtration subsystem shall be demonstrate. oDEr BLE:
/ -..: ms l
a.
At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in OhERATIONAL C5NoITION', ey verifying i
one Fuel Building Ventilation Charcoal Filtration System operation.
d b.
l j At least once per 31 days by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that
- i the subsystem cperates for at least 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> with the heaters GPERABLE.
i 3
)
"When irraciated fuel is being handled in the ' ^^f"dw/ ding ^t -d :. ' s Fa
]
y 20 1 i ;
9 CO": ALT:'OM: :-' ^;; :t " ~ U " : p:terti:' # - * :ini ; th; - :: :- wc h 4
RIVER BEND - UNIT 1 3/4 6-61 4>; g g
.... y; u. g CONTAINMENT SYSTEMS g
SUR/EILLANCE REQUIREMENTS (Continued)
At least once per.18 months or (1) after any structural haintenance c.
on the HEPA filter or charcoal adsorber housings or (2) following painting, fire or chemical release in any ventilation zone cortmuni-cating with the subsystem bj:
1.
Verifying that the subsystem satisfies the in place penetration and bypass leakage testing acceptance criterion of less than 0.05%, using the test procedure guidance in Regulatory Positio n C.S.a, C.5.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and a system flow rate of 10,000 cfm 10%.
2.
Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, Marcr.1978, j
for a methyl fodide penetratien of less than 0.175%; and i
3.
Verifying a subsystem flow rate of 10,000 cfm 2 10% during system i
operation when tested in accordance with ANSI N510-1975.
1 d.
After every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> cf charcoal adsorber operation, by verifying within 31 days after removel that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration of less than 0.175%.
Ge.
At least once per 18 months by:
1.
Performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence for the:
a)
LOCA, and FJ Ao b)
AfmeAis ventilation exhaust high radiation signal.
2.
Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 8 inches water gauge while the filter train is operating at a flow rate of 10,000 cfm
, l 2 10%.
I i
3.
Verifying that the subsystem sta.-ts and isolation dampers actuate to isolate the normal flow path and to divert flow through the charcoal filters on each of the following test signals:
RIVER BEND - UNIT 1 3/4 6-62 APR 2 61985
=
y
.g F!N** p1.faJer
/
CONTAINMENT SYSTEMS g
3/4.6.6 ATMOSPHERE CONTROL PRIMARY CONTAINMENT HYOROGEN RECOMBINER SYSTEMS LIMITING CONDITION FOR OPERATION 3.6.6.1 Two independent primary containment hydrogen recombine.r_ sy. stems shall be OPERABLE.
A9PLICABILITY: OPERATIONAL CONDITIONS 1 and 2.
ACTION:
i With one primary containment hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
2 SURVEILLANCE RE0VIREMENTS
)
q a
4.6.6.1 Each primary containment hydrogen recombiner system shall be demon-strated OPERABLE:
(
At least once per 6 months by verifying, during e. recombiner system a.
i functional test that the minimum heater sheath temperature increases to ater than or equal to 700'F within 90 minutes %d e.s 6 s'%
At least once per 18 months by:
b.
1.
Performing a CHANNEL CALIDRATION of all control room recombinee indication instrumentation and control circuits 2.
Verifying through a visual examination that there is no evicence a
of abnormal conditions within the recombiner enclosure; i.e.,
loose wiring or structural connections, deposits of foreign materials, etc.
i i
,a 3.
Verifying the integrity of all heater electrical circuits by l 3 performing a resistance-to ground test within 30 minutes follow-l ing the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohms.
4 Verifying, during a 'recombiner system functional test, that the l
heater sheath temperature increases to greater than or equal to 1215*F within 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />
/ m..j.m,. of f, q b e
i RIVER BEND - UNIT 1 3/4 6 64 D 2 5 7-
{'
~ ~ -
,v FlE. BEF TABLE 3.6.6.3-1 HYOROGEN IGNITERS AND LOCATIONS DIST. FROM IGNITER" DIVISION ELEVATION AZIMUTH OF REACTOR CENTERLINE NORMALLY ACCESSIBLE Ocen Areas Containment 1A I
EL 255-0
- 0. 0 20.0' 18 II EL 255-0 90.0 20.0' 2A I
EL 255-0 180.0 20.0'
~
28 II EL 255-0 270.0 20.0' 3A I
EL 250-0 337.5 33.0'
.S 3B II EL 250-0 22.5 38.0'
?
4A I
EL 250-0 67.5 38.0' 4B II EL 250-0 112.5 38.0' 5A I
EL 250-0 157.5 38.0' 5B II EL 250-0 202.5 38.0' 6A I
EL 250-0 247.5 38.0' C
6B II EL 250-0 292.5 38.0' 7A I
EL 239-0 315.0 56.0' i
78 II EL 239-0 0.0 56.0' 8A I
EL 239-0 45.0 56.0'
. 8B II EL 239-0 90.0 56.0'
. 9A II EL 239-0 180.0 56.0' I
EL 239-0 135.0 56.0' 98 10A I
EL 239-0 225.0 56.0' 10B II EL 239-0 270.0 56.0' 11B II EL 173-q 27.0 48.3' 12A I
EL 173 6 64.0 4 0- O' 5 7. o,
128 II EL L 170 & 174-6 88.9 53.0' 14A I
EL WiH 873-o MiHi. is c. o 4s--s' 6 o o '
14B II EL 169-9 153.9 52.3' l
15A I
EL 183-6 238.0 56.6' 150 II EL 183-6 ft9 D't. o M-.F-f6. t '
20A I
EL WiHir I& t-o 293.9 54.1' 20B II EL 170-0 319.0 SG-t' r o. r,
22A I
EL 150-0 4 &r 4 2.t. i 60-+' r t. 4 '
22B II EL 154-0 63.0 60.0' 23A I
EL 159-6 84.0 60.0' 23B II EL 152-0 Hs.4 fir.o
- . 3 ' s o. o' 24A I
EL MG-4irY-o 153.0 M-e.' 6 o. o '
24B II EL 128-0 145-+ fr3. o
' 51. l '
,, f 16 A I
EL t17-o 2.49.7 s 3.5-(, 16 8 II EL172. 0 2.'ro a r 7. o s
- Prefix is INCS*1GNOM-for all igniters.
RIVER BEND - UNIT 1 3/4 6-68 tyt 2 3 385
s.2ew FlhAL DRUT TABLE 3.6.6.3-2 (Continued) 1 HYOROGEN IGNITERS AND LOCATIONS DIST. FRCM l
J CENTERLINE IGNITER"
'IVISION ELEVATION AZIMUTH OF REACTOR NORMALLY ACCESSIBLc (Continued)
Open Areas Containment (Continued) 25A I
EL 159-6 210.0 50.0' 25B II EL 151-0 238.0 M-4.' f o. o '
27A I
EL M H ir3-4 321.1 46.2' 27B II EL 152-7 294.8 52.3' 32A I
EL HG-4. I3 o -o -
66 G. 61. o go. o '
f+:+ d'o. o ),
32B II EL 126-0 30.0 33A I
EL M641tv-o HH t ir.c 60.0' 338 11 EL 126-0 90.0 60.0' 34A I
EL 126-0 180.0 47.0' 34B II EL 139-4 209.0 54.2'
- A I
CL 100 0 155.1
'5.E'
[
II EL 100 C 170. v.
t5.C' 38A I
EL 139-4 240.5 54.0' 388 II EL 126-0 270.0 60.0' 39A I
EL 126-6 es,1-4. "2.i f. S~
60.0' 39B II EL 130-0 M6-4 31f.o M rr.v'
-43A I
EL He-e lor-1 N G-9-320.0 4P 27. r '
.438 II EL He-4iot-o 5.0 4G,4 31. r
- 44A I
E L Mf-+ 1 s t -5~
39.0 44-4.'y4.5' l
44B II EL M1 0to3-o 4a-4. dr.o 49 4.' 3 s. r '
45A I
E L Hi-+ 1 s o - o 9G 4 S r.o 49-e 39.r' 45B II EL 112-5 M4-4.'l l7. o 49-@ N 2.2 '
46A I
ELH64 81 -r EW41rr. o 44-e.' 9 4. r '
46B
.II EL 112-5 MG-4176. o 4fHpvtir*
47A I
EL 112-5 297-4 tov. e 49-s' vi.r
- 47B II EL 112-5 0444 m o 49-4H N3.o' 48A I
EL Hi-41oi-6 g + s-0 2 6 r.o 44 e.' 3 3. r '
i 488 II EL Hi-4 Io f -6 GM-G "Lil o 494'31.r' l
l
" Prefix is INCS*IGNGth-for all igniters.
i l
RIVER BEND - UNIT 1 3/4 6-69 i
E 2 6 199 5
_ TABLE 3.6.6.5-1 (Continued)
?;
18 w./dJ'P
- - w=
HYDRDGEN IGNITERS AND LOCATIONS DIST. FROM IGNITER" OIVISION
_ ELEVATION CENTERLINE AZIMUTH OF REACTOR NORMALLY INACCESSIBLE Open Areas Drywell 28A I
EL 156-0
- 0. 0 24.8' 288 II EL 156-0 44-4 77.o 29A I
44,4123.P '
EL 156-0 125.0 21.5' 298 II EL 156-0 180.0 25.0' 30A I
EL 156-0 233.0 22.0' 308 II EL 156-0 306.0 21.0' 40A I
EL 138-8 293.3 25.0' 408 II EL 133-1 359.2 18.8' 41A I
EL 139-10 60.4 21.6' 418 II EL 133-5 129.9 21.8' 42A I
EL 138-11 179.0 23.0' 428 II
[
49A I
EL 135-10 240.0 22.0'
\\
EL 136-8 354.5 26.0' 498 II EL 116-6 66.8 20.9' 50A I
EL 116-7 113.4 21.2' 508 II EL 116-7 180.0 21.0' 51A I
EL 115-2 247.3 20.8'
,_518 II EL 116-6 292.9 21.2'
_ Enclosed Areas RWCU Heat Exchanger Room 11A I
EL 166-6 20.8 50.5' 21A I
EL W.r-fr I(7
't iBfh+ 37S.I w v r. o '
218
.II EL MS-i> 1 & 7 - 6 4- ;'- N. o 4s-s ' 4 3 M '
Contaminated Equip. Store Room 13A I
EL 167-3 52.1 29.2' 138 II E'. 167 123.6 32.4'
- Prefix is IMC$*IGN&lA-for all igniters.
.\\s RIVEk BEND - UNIT 1 3/4 6-70
.gpn 2 61935
e'
.. ; :.;.%.Us n FINAL DEF"k TABLE 3.6.5.3-1 (Continued)
_ HYDROGEN IGNITERS AND LOCATIONS DIST. FROM IGNITER"
_0! VISION CENTERLINE ELEVATION AZIMUTH OF REACTOR NOR.d. ALLY INACCESSIBLE (Continued)
Enclosed Areas (Continuec)
WC" C:.t :! ^. -
19 I
[L 170 0 2;0. 0
- 0.0'-
100 CL 172 0 200.0
- 0. 0 '
RWCU Valve Nest and Pump' Room 17A I
170-6 2tr.v Vo.o El t92-t 4%-3 44,.Ga
.)
17B II EL 93 4+e 4HH RWCU Filter Demin A Room 18A I
EL 173-0 235.3 31.6' 18a II EL 173-0 260.1 23.3'
\\
RWCU Filter Demin B Room 19A I
3o3.9 31.3' EL 175-6 Pe6-t 07.l' 198 II EL 174-6 282.3 23.5' RWCU Backwash Room Ir7-4 26A I
EL W Hi.
247.5 49.6' 268 II EL 150-0 276.1 46.8' Main Steam Tunnel 31A I
EL 126-0 341.9 51.5' 318
.II EL 126-0
'17.4 53.5' SFC Piping and Valve Area 36A I
EL 136-0 368 II
%6-G-14 4.3
.56.4' EL 136-0 185.6 57.3' Drywell H~teL Ara,.
3fA I
EL 136-0 I sT.i W.t '
35'8 H.
EL 13 6 - 0 I 7 t.'l Mr. o '
" Prefix is 1HCS*1GN69-for all igniters.
RIVER BEND - UNIT 1 3/4 6-71 APR 2 61985
~
.,__.3 TABLE 3.6.6.3-1 (Continued)
HYDROGEN IGNITEES AND LOCATIONS DIST FRCM IGNITER" DIVISION ELEVATION CENTERLINE AZIMUTH OF REACTOR NORMALLY INACCESSIBLE (Continued)
_ Enclosed Areas (Continued).
Fuel Transfer Tube Area i
37A I
EL 135-0 378 II 202.1 EL 134-0 39.g' 201.3 49.4' Upper Fuel Pool Valve Room
~
52A I
t, gt 179 3 528 II 1
80.5 EL 179-3 30.3' 138.8 33.2'
" Prefix is 1HC5"IGNG4A-for all igniters.
h s
i t
4 1
s RIVER BEND - UNIT 1 3/4 6 72 l
APR 2 61985 t
l L
u..
2$fdd. bilfl((
TA.BLE 3.6.6.3-2 HYDROGEN IGNITERS AND ASSOCIATED CIRCUITS ##
DIVISION I(a)
CIRCUIT 1 CIRCUIT 2 CIRCUIT 3 CIRCUIT 4 CIRCUIT 5 8A 9A 49A#
51A#
44A 7A 10A 50M 42M 32A 3A 6A 41M 40M 33A 4A SA 29A#
30M 1A
. 2A 28A#
22A 11Av 13A#
CIRCUIT 6 CIRCUIT 7 CIRCUIT 8 CI.RCUIT 9 CIRCUIT 10 I 46A 36A#
37A#
47A 43A i
l l.
35A#
34A 48A 38A 31M 45A 25A 39A 18A#
27A 23A 26A#
17 20A 21M 16[A#
12A 24A ISA 19M i
14A l
52A#
t 1
- Igniters in inaccessible areas
- Prefix is 1HCS*IGNHA-for all igniters.
(a)A minimum of 48 igniters shall be OPERABLE.
t RIVER BEND - UNIT 1 3/4 6-73
'993?2
,,. ~...
s'
.. _ ~_.. - -
_ TABLE 3.6.6.3-2 (Continued)
HYOROGEN IGNITERS AND ASSOCIATED CIRCUIT DIVISION II(a)
CIRCUIT 1 CIRCUIT 2 CIRCUIT 3 CIRCUIT 4 CIRCUIT 5 78 98 498#
519#
438 8B 10B SOB #
42B#
31B#
-i 38 58 418#
298#
328 48 68 40B#
30B#
218#
18 28 2BB#
llB 52BN CIRCUIT 6 CIRCUIT 7 CIRCUIT 8 CIRCUIT 9 CIRCUIT 10 f k
44B 11 358#.
46B 37B#
47B 1
45B 368#
258 48B 39B 33B 34B 17B#
38B 268#
'i 23B 248 188#
19 d
'22R 13B#
15B 27B 128 148 16 208 t
.~
- Igniters in inaccessible areas
- Prefix is 1HC5"IGNGM-for all igniters.
(a)A minimum of 48 igniters shall be OPERABLE.
t i
s' 1
^
RIVER BEND - UNIT 1 3/4 6-74 APR 2 61985 i
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F Fjji d g"-'j 5r 3.4.6 CONTAINMENT SYSTEMS BASES 3/4.6.1 CONTAINMENT 3/4.6.1.1 and 3/4.6.1.2 PRIMARY CONTAINMENT INTEGRITY PRIMARY CONTAINMENT INTEGRITY (OPERATING and FUEL HAND the release of radioactive materials from the primary containment atmosphere will be restricted to those leakage paths and associated leak rates assumed in the accident analyses. This restriction, in conjunct, ion with the leakage rate limitation, will limit the site boundary radiation doses to within the limits of 10 CFR Part 100 during accident conditions.
3/4.6.1.3 PRIMARY CONTAINMENT LEAKAGE The limitations on primary containment leakage rates ensure that the total primary containment leakage volume will not exceed the value assumed in the 2
i accident analyses at the peak accident pressure of 7.6 psig, Pa.
As an added i
conservatism, the measured overall integrated leakage rate is further limited
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to less than or equal to 0.75 La during performance of the periodic tests to account for possible degradation of the primary containment leakage barriers
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between leakage tests.
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Operating experience with the main steam line isolation valves has indi-cated that degradation has occasionally occurred in the leak tightness of the j
valves; therefore the r,pecial requirement for testing these valves.
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The surveillance testing for measuring leakage rates is consistent with the sequirements of Appendix J to 10 CFR 50,rith th:
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3/4.6.1.4 PRIMARY CONTAINMENT AIR LOCKS
.1 The limitations on closure and leak rate for the primary containment air i
locks are required to meet the restrictions on PRIMARY CONTAINMENT INTEGRITY-OPERATING and the primary containment leakage rate given in Specifica-tions 3.6.1.1 and 3.6.1.3.
The specification makes allowances for the fact that there may be long periods of time when the air locks will be in a closed
,l l and secured position during reactor operation. Only one closed door in each cir lock is required to maintain the integrity of the primary containment.
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RIVER BEND - UNIT 1 8 3/4 6-1 APR 2 61985 l
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